Ball lift sleeve and retrieval tool for oil and gas wells

ABSTRACT

A ball lift sleeve and retrieval tool comprising a sleeve for disposing in tubing of a well, the sleeve defining a first passage from a first proximal end to a first distal end, and a retrieval tool for disposing in the tubing of the well, the retrieval tool being separately moveable in the tubing between mated and unmated conditions with respect to the sleeve, the retrieval tool at least partially mating with the first distal end of the sleeve when in the mated condition and at least partially closing fluid communication through the passage of the sleeve when mated therewith.

CROSS-REFERENCE TO RELATED APPLICATION

This application claims the benefit of U.S. Provisional PatentApplication Ser. No. 62/883,653 filed Aug. 7, 2019, titled “Multi-PiecePlunger,” and U.S. Provisional Patent Application Ser. No. 62/927,495filed Oct. 29, 2019, titled “Ball Lift Sleeve Retrieval Tool for Oil andGas Wells,” and the subject matter thereof is incorporated herein byreference thereto.

TECHNICAL FIELD

The present invention relates generally to oil and gas wells, and moreparticularly to ball sleeve and retrieval tool used in a multi-pieceplunger lift system.

BACKGROUND ART

Plunger lift systems are consistently used in oil and gas wells. Thesesystems rely on natural buildup of pressure in a shut-in gas well andgas velocity in a well struggling to flow. A bumper spring is in placeat the bottom of the well where the plunger cycle begins. When the wellis shut-in, the plunger falls through the gas and liquid toward thebumper spring. The plunger then travels up toward the surface when thewell is opened. There is typically a controller that opens a valve thatcontrols the shut-in pressure and creates a differential pressure thatforces the plunger and the liquid to the surface. The plunger provides aseal between the liquid and the gas, which allows for the well's ownenergy to be used to lift liquids out of the well.

Plunger lift systems are well-known in the prior. They are typicallyused in oil and gas wells to remove liquids from the wellbore, utilizingthe pressure in the well. U.S. Pat. No. 9,869,165 B2, Hightower et al.,entitled “Plunger Lift Arrangement” (the “165 Patent”), U.S. Pat. No.9,297,247 B2, Lea, Jr., entitled “Plunger Lift Slug Controller,” U.S.Pat. No. 8,485,263 B2, Lembcke, entitled “Multi-Sleeve Plunger forPlunger Lift Systems,” are just a few of the recent patents that aretargeted toward plunger lift systems.

There are many types of lifting plunger, as seen for example in thereferenced patents, that have been developed to address many of theproblems encountered by two piece plungers. The industry has tried manyvariations of these types, including, internal dart, shift rod, andshift collapsing plungers, just to name a few. Each of these variationshave their own drawbacks.

Two piece plungers were a huge step in the industry as they provided ameans to move large amounts of liquids with little off time. The twopiece plunger falls against flow and rises bringing liquid to surfacecontinuously with little interruption in flow. This type of plunger waseven challenging the use of pumping units, pump jacks. These pump jacksare much more expensive artificial lift systems used to handle theseconditions. This development in plunger technology meant the rest of theplunger lift companies had to catch up.

The problems encountered by the plungers contained in the prior are,including, but not limited to: 1) the impurities in gas and liquidproduction are present and have to be addressed; 2) various flow ratesand velocities are in encountered over production days requiring plungeradjustments (opening, closing ports, checking shifting mechanism,adjusting clutches, etc.) daily by skilled people; 3) as the plunger isfalling, the shifting mechanism will slam shut when it hits liquid,sending the plunger to the surface with no load at high rates of speedcausing extreme damage and hazards. Note that the maximum velocityattainable by plunger is the speed of sound; 4) most have to be designedspecifically for the wells and are not readily interchangeable withother wells, with flow rates and liquid rates at the time ofinstallation. This can include different inner diameter and outerdiameter bores, specific port sizing, and shifting valves sizes; and 5)not including labor skill level required to operate, these plungers cost3 to 5 times that of a two piece sleeve.

Referring to problem 1) listed above, if there is a valve shifting thatgets stuck by a little sand, it stops running, creating a restriction intubing bore and having to be mechanically removed. If one of the portsget trash, it will not get to the bottom. If the shifter gets stuck inopen position it will stay on bottom and not come back up to thesurface. This means it is highly labor intensive and requires skilledoperators to maintain. This is the one of the greatest problems in thistype of system

With all of that said, why do producers use these systems predominatelyover the two-piece pacemaker. The 165 Patent has operating parametersthat are vastly different from conventional plunger operations, thusrequiring extensive training and diligence by the operators. Pumpoperators want fast fall even under flowing conditions. Most need anduse standing valves at bumper springs so when the sleeve does not makecontact with the ball, the only way to retrieve it is with a wire lineor a rig. The shifting type can be blown to surface 95% of the time.

The first two piece plungers used on high gas volume medium liquid ratewells with great results. As the wells matured rates fell and the issuesthe present invention addresses appeared. Until a few years ago, theindustry could not tell what was going on. The Echometer companydeveloped a program fast enough to track these fast plungers running at1000 hz. Although relatively new and unknown to the industry, we are nowable to see the problems. When Encana found and started developing theSan Juan basin oil play on horizontal wells, it was a testing ground fora new type of production technique.

Operators and employees were cherrypicked and everything was tried. Theonly rule was to prove the processes and to lower the cost after proven.That brings us to today. The industry only uses two piece plungers forproduction in oil barrel rates from 10 to 800 per day with gas ratesfrom 13 to 2,300 Mcfd.

Plunger lifts are typically used in high gas/liquid ratio gas and oilwells but are versatile enough to be used in lower gas/liquid ratiowells as well. A two piece plunger lifts fluids when the ball and sleeveare coupled, but the ball and sleeve are designed to fall when separate.As with other artificial lift methods, the purpose of a plunger lift isto remove liquids from the wellbore so that the well can be produced atthe lowest bottom-hole pressure and maximum rate. Sleeve and two pieceplungers contained in the prior art do not address certain problems inthe industry, specifically the fact that the flow characteristics at thebottom of the hole are different than the flow in the tubing and casingproduction string. At the area above the bumper spring and toapproximately 600 feet above the bumper spring, the gas and liquid isforced to the walls of the tubing by the bumper spring.

As flow moves up the tubing, the friction on the outside of the tubingredirects the velocity to the center of the tubing, thus forming asealing between the ball and the sleeve, and in turn pushing the sleeveand ball to the surface. The area where the flow characteristics change,the transition area, is where problems arise. There are problems withgetting the lifting sleeve through the transition area, and inhorizontal production, these problems are only compounded. Oftentimes,the velocity of flow on the wall will stop the sleeve from reaching theball. If that happens, the ball may drop before reaching the transitionarea, causing a drop in pressure of the entire system. The industrycalls this the “yo-yo effect” or “dropping the ball.”

Dropping the ball increases tubing wear (by making so many liftingattempts to achieve one actual lift, wearing holes in bottom of tubing,etc.), plus dropping multiple loads logging off wells. Therefore, mostproducers are afraid of these types of lift systems. Producers want andneed fast fall rates, making the need for the decrease in dropping theball rates a huge boom for the industry.

The present invention provides a two piece plunger lift (ball andsleeve) for use in oil and gas wells. More specifically, a plunger lifthaving a sleeve with a bore thru that is positioned between a bumperspring and ball. Gas flow will lift the sleeve off the bumper springcarrying the ball through an impacted area until making contact with thedescending plunger at which point it is inserted into plungertransferring upward lift to plunger. The sleeve will then descend backto the bumper spring and await the ball to drop and be inserted in topof sleeve which will act as check valve holding fluid in tubing untilnext cycle.

The present invention works in conjunction with prior art sleeves and/ortwo piece plungers to address and overcome problems by providing adevice that delivers the load out of the transition area simply withoutadjustments required. Many prior art systems use a small sleeve insteadof a ball and latch type upper sleeve instead of a separator rod. Priorart sleeves have limited flow through the center, causing a very slowdescent to reach the bumper spring. Even a more hollow sleeve still hasenough restriction in the last approximately 300 feet or so from thebumper spring due to the formation pressure and compressor injectionpushed to the outside of the tubing by the head of the bumper springthat it is slowed, and oftentimes comes to a complete stop. This meansthe sleeve is unable to connect with the ball, and no seal can beformed. The present invention provides is designed to continuouslyoperate by carrying the ball through this restricted area up to thepoint that the upward pressure comes off the outside of the tubing andis equal pressure throughout the walls of the tubing allowing thepressure to flow through the center of the upper cylinder more freelywhich improves time efficiency of each cycle immensely

The present invention provides a ball and ball lift sleeve to be used inplunger lift gas/liquid wells. To easily remove the ball lift sleeve ofthe present invention out of the well when not in use, a special tool isneeded. Two such embodiments of tools to remove the ball lift sleevefrom the well are included in the present invention.

Certain embodiments of the invention have other steps or elements inaddition to or in place of those mentioned above. The steps or elementwill become apparent to those skilled in the art from a reading of thefollowing detailed description when taken with reference to theaccompanying figures.

None of the prior art fully addresses the problems resolved by thepresent invention. The present invention overcomes these limitationscontained in the prior art by providing a multi-piece plunger and ballsleeve retrieval tool for plunger lift systems that is sturdy, reliable,easy to use, and inexpensive.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a side perspective view of ball lift sleeve.

FIG. 2 illustrates a cross-sectional side perspective view of ball liftsleeve.

FIG. 3 illustrates a cross-sectional side elevation view of ball liftsleeve.

FIG. 4 illustrates a cut-away side perspective view of ball lift sleeve.

FIG. 5 illustrates a schematic representation of a plunger lift well.

FIG. 6 illustrates a partial side perspective view of ball lift sleeveand bumper spring disposed in tubing.

FIG. 7 illustrates a partial side perspective view of ball lift sleevewith ball and bumper spring disposed in tubing.

FIG. 8 illustrates a partial side perspective view of lift sleeve andball disposed in ball lift sleeve.

FIG. 9 illustrates a partial side perspective view of coupled liftsleeve and ball lift sleeve disposed in tubing.

FIG. 10 illustrates a partial side perspective view of ball lift sleeveand ball disposed in lift sleeve.

FIG. 11 illustrates a schematic representation of a plunger lift well.

FIG. 12 illustrates a schematic representation of a plunger lift well,lift sleeve, and ball.

FIG. 13 illustrates a cross-sectional side elevation view of ball liftsleeve retrieval tool.

FIG. 14 illustrates a partial side perspective view of the ball liftsleeve retrieval tool and ball lift sleeve retrieval tool catch.

FIG. 15 illustrates a cut-away side perspective view of the ball liftsleeve and ball lift sleeve retrieval tool.

FIG. 16 illustrates a partial side perspective view of ball lift sleeveand ball lift sleeve retrieval tool.

FIG. 17 illustrates a partial side perspective view of ball lift sleeve,ball lift sleeve retrieval tool, and bumper spring.

FIG. 18 illustrates a partial side perspective view of ball lift sleeve,ball lift sleeve retrieval tool, and bumper spring.

FIG. 19 illustrates a cross-sectional side elevation view of alternateball lift sleeve retrieval tool.

FIG. 20 illustrates a partial side perspective view of the alternateball lift sleeve retrieval tool, alternate ball lift sleeve retrievaltool male receiver, alternate ball lift sleeve retrieval toolmid-section, and D-rings.

FIG. 21 illustrates a bottom up view of the alternate ball lift sleeveretrieval tool, comprising alternate ball lift sleeve retrieval toolmale receiver, alternate ball lift sleeve retrieval tool main body, andD-rings.

FIG. 22 illustrates a cut-away side perspective view of the ball liftsleeve and alternate ball lift sleeve retrieval tool.

FIG. 23 illustrates a cut-away side perspective view of the ball liftsleeve and ball lift sleeve retrieval tool.

FIG. 24 illustrates a partial side perspective view of the ball liftsleeve and alternate ball lift sleeve retrieval tool in tubing.

FIG. 25 illustrates a side perspective view of the ball lift sleeve andalternate ball lift sleeve retrieval tool in tubing.

DETAILED DESCRIPTION OF THE INVENTION

The best mode for carrying out the invention will be described herein.The following embodiments are described in sufficient detail to enablethose skilled in the art to make and use the invention. It is to beunderstood that other embodiments would be evident based on the presentdisclosure, and that system, process, or mechanical changes may be madewithout departing from the scope of the present invention.

In the following description, numerous specific details are given toprovide a thorough understanding of the invention. However, it will beapparent that the invention may be practiced without these specificdetails. To avoid obscuring the present invention, some well-knownsystem configurations, and process steps are not disclosed in detail.The figures illustrating embodiments of the system are semi-diagrammaticand not to scale and, particularly, some of the dimensions are for theclarity of presentation and are shown exaggerated in the drawingfigures.

Alternate embodiments have been included throughout, and the order ofsuch are not intended to have any other significance or providelimitations for the present invention.

For expository purposes, the term “horizontal” as used herein is definedas a plane parallel to the plane or surface of the plunger and ball liftsleeve retrieval tool or the oil/gas well, as the case may be,regardless of its orientation. The term “vertical” refers to a directionperpendicular to the horizontal as just defined. Terms, such as “above”,“below”, “bottom”, “top”, “side”, “higher”, “lower”, “upper”, “over”,and “under”, are defined with respect to the horizontal plane, as shownin the figures.

The present invention provides a ball and ball lift sleeve to be used inplunger lift gas/liquid wells. To easily remove the ball lift sleeve ofthe present invention out of the well when not in use, a special tool isneeded. Two such embodiments of tools to remove the ball lift sleevefrom the well are included in the present invention.

FIG. 1 illustrates a side perspective view of ball lift sleeve 101. Ballseat 102 is disposed in the inner diameter of ball lift sleeve 101.

FIG. 2 illustrates a cross-sectional side perspective view of ball liftsleeve 101. Flow thru 202 extends through ball lift sleeve 101. Ballseat 102 is disposed in the inner diameter of ball lift sleeve 101 atthe distal end of flow thru 202. Catch groove 201 is disposed in balllift sleeve 101.

FIG. 3 illustrates a cross-sectional side elevation view of ball liftsleeve 101. Flow thru 202 extends through ball lift sleeve 101. Ballseat 102 is disposed in the inner diameter of ball lift sleeve 101 atthe distal end of flow thru 202. Catch groove 201 is disposed in balllift sleeve 101.

FIG. 4 illustrates a cut-away side perspective view of ball lift sleeve101. Flow thru 202 extends through ball lift sleeve 101. Ball seat 102is disposed in the inner diameter of ball lift sleeve 101 at the distalend of flow thru 202. Catch groove 201 is disposed in ball lift sleeve101. Thickness of ball lift sleeve wall 401 can vary as required.

FIG. 5 illustrates a schematic representation of a plunger lift well501. Lift sleeve 502 is disposed in tubing 504, which deploys in casingproduction string 507. Ball 503 is disposed in tubing 504 between liftsleeve 502 and ball lift sleeve 101. Bumper spring 505 and perforations506 are at the distal end of the plunger lift well 501. The size of ball503 is such that flow goes all around it when it is disposed in tubing504.

Ball lift sleeve 101 has flow thru 202 that defines ball seat 102. Ball503 fits against ball seat 102, sealing fluid flow through flow thru 202during operation. The outer surface of ball lift sleeve 101 can haveribbing or other means for creating a desired pressure differential.When in use, ball lift sleeve 101 and ball 503 dispose separately intubing 504. Ball lift sleeve 101 is dropped first to land near thebottom of the well, falling into any liquid near the bottom of the welland contacts bumper spring 505. Ball 503 is then dropped into tubing504.

When ball 503 reaches ball lift sleeve 101, they come into contact toform a seal. Once the seal is formed, the well can be operated. Gasenters through perforations 506 and travels up the tubing 504 to thesurface. Liquid that accumulate in the well creates back pressure thatslows gas production. Eventually, gas flow will lift coupled ball 503and ball lift sleeve 101 off bumper spring 505 and bring them toward thesurface. This allows for the liquid load to be removed from the well.

Coupled ball lift sleeve 101 and ball 503 makes contacts with liftsleeve 502. Coupled ball 503 and lift sleeve 502 makes contact with thedescending the plunger of plunger lift well 501 at which point it isinserted into plunger transferring upward lift to plunger. Ball liftsleeve 101 descends back toward the bumper spring 505 and awaits theball 503 to drop and be disposed in ball seat 102 of ball lift sleeve101, acting as check valve holding fluid in tubing 504 until next cycle.

FIG. 6 illustrates a partial side perspective view of ball lift sleeve101 and bumper spring 505 disposed in tubing 504.

FIG. 7 illustrates a partial side perspective view of ball lift sleeve101 with ball 503 and bumper spring 505 disposed in tubing 504. Ball 503is disposed in ball seat 102 of ball lift sleeve 101.

FIG. 8 illustrates a partial side perspective view of lift sleeve 502and ball 503 disposed in ball lift sleeve 101.

FIG. 9 illustrates a partial side perspective view of coupled liftsleeve 502 and ball lift sleeve 101 disposed in tubing 504.

FIG. 10 illustrates a partial side perspective view of ball lift sleeve101 and ball 503 disposed in lift sleeve 502.

FIG. 11 illustrates a schematic representation of a plunger lift well501. Lift sleeve 502 is disposed in tubing 504. Ball 503 is disposed inlift sleeve 502. Ball lift sleeve 101 has disengaged with ball 503 andlift sleeve 502, falling down the well and contacting bumper spring 505.At this point, upward lift has been transferred to the plunger, createdby the coupled ball 503 and lift sleeve 502.

FIG. 12 illustrates a schematic representation of a plunger lift well501, lift sleeve 502, and ball 503.

FIG. 13 illustrates a cross-sectional side elevation view of ball liftsleeve retrieval tool 1301. The ball lift sleeve retrieval tool 1301 isonly used if ball lift sleeve 101 becomes stuck or needs to beinspected. Ball lift sleeve retrieval tool 1301 comprises ball liftsleeve retrieval tool main body 1303 and ball lift sleeve retrieval toolmale receiver 1304. Ball lift sleeve retrieval tool catch 1302 isdisposed on ball lift sleeve retrieval tool male receiver 1304. Whenball lift sleeve retrieval tool 1301 and sleeve 101 are mated together,they move uphole within tubing 504 by application of a pressuredifferential.

Ball lift sleeve retrieval tool 1301 contains inner diameter hollowsection 1305 which begins at the top of ball lift sleeve retrieval tool1301 and extends partially through ball lift sleeve retrieval tool mainbody 1303. Inner diameter hollow section 1305 is used in case acommercial tool is needed to retrieve ball lift sleeve retrieval tool1301 from tubing 504. Commonly used commercial tools are standard in theindustry for retrieving plungers and fit into inner diameter hollowsection 1305.

FIG. 14 illustrates a partial side perspective view of the ball liftsleeve retrieval tool 1301 and ball lift sleeve retrieval tool catch1302.

FIG. 15 illustrates a cut-away side perspective view of the ball liftsleeve 101 and ball lift sleeve retrieval tool 1301. Ball lift sleeveretrieval tool male receiver 1304 of ball lift sleeve retrieval tool1301 is disposed in ball lift sleeve 101. Ball lift sleeve retrievaltool catch 1302 is disposed in catch groove 201. Means for releasingball lift sleeve retrieval tool catch 1302 allows for the de-coupling ofball lift sleeve retrieval tool 1301 and ball lift sleeve 101.

FIG. 16 illustrates a partial side perspective view of ball lift sleeve101 and ball lift sleeve retrieval tool 1301. Ball lift sleeve retrievaltool 1301 is not yet in contact with ball lift sleeve 101. The diameterof ball lift sleeve retrieval tool 1301 is such that it fits snugly intubing 504.

FIG. 17 illustrates a partial side perspective view of ball lift sleeve101, ball lift sleeve retrieval tool 1301, and bumper spring 505. Atthis point, ball lift sleeve retrieval tool catch 1302 is securablydisposed in catch groove 201, and ball lift sleeve 101 and ball liftsleeve retrieval tool 1301 are securably attached. Ball lift sleeve 101is disposed on bumper spring 101, allowing for ball lift sleeveretrieval tool 1301 to be inserted into ball lift sleeve 101.

FIG. 18 illustrates a partial side perspective view of ball lift sleeve101, ball lift sleeve retrieval tool 1301, and bumper spring 505. Balllift sleeve 101 and ball lift sleeve retrieval tool 1301 are securablyattached.

In an alternate embodiment of the present invention, FIG. 19 illustratesa cross-sectional side elevation view of alternate ball lift sleeveretrieval tool 1901. The alternate ball lift sleeve retrieval tool 1901functions similarly to ball lift sleeve retrieval tool 1301 and is onlyused if ball lift sleeve 101 becomes stuck or needs to be inspected.Alternate ball lift sleeve retrieval tool 1901 comprises alternate balllift sleeve retrieval tool main body 1902, alternate ball lift sleeveretrieval tool male receiver 1906, alternate ball lift sleeve retrievaltool mid-section 1904, and D-rings 1905. D-rings 1905 are attachedrotatably to alternate ball lift sleeve retrieval tool mid-section 1904such that D-rings 1905 can be rotated toward alternate ball lift sleeveretrieval tool main body 1902, while remaining attached to alternateball lift sleeve retrieval tool mid-section 1904. When alternate balllift sleeve retrieval tool 1901 is in the upright position, D-rings 1905rest on alternate ball lift sleeve retrieval tool male receiver 1906.Alternate ball lift sleeve retrieval tool male receiver 1906 fits snuglyin flow thru 202 of ball lift sleeve 101.

Alternate ball lift sleeve retrieval tool 1901 contains alternate innerdiameter hollow section 1903 which begins at the top of alternate balllift sleeve retrieval tool 1901 and extends partially through alternateball lift sleeve retrieval tool main body 1902. Alternate inner diameterhollow section 1903 is used in case a commercial tool is needed toretrieve alternate ball lift sleeve retrieval tool 1901 from tubing 504.Commonly used commercial tools are standard in the industry forretrieving plungers and fit into alternate inner diameter hollow section1903.

FIG. 20 illustrates a partial side perspective view of the alternateball lift sleeve retrieval tool 1901, alternate ball lift sleeveretrieval tool male receiver 1906, alternate ball lift sleeve retrievaltool mid-section 1904, and D-rings 1905.

FIG. 21 illustrates a bottom up view of the alternate ball lift sleeveretrieval tool 1901, comprising alternate ball lift sleeve retrievaltool male receiver 1906, alternate ball lift sleeve retrieval tool mainbody 1902, and D-rings 1905.

FIG. 22 illustrates a cut-away side perspective view of the ball liftsleeve 101 and alternate ball lift sleeve retrieval tool 1901. Alternateball lift sleeve retrieval tool male receiver 1906 and alternate balllift sleeve retrieval tool mid-section 1904 are disposed in ball liftsleeve 101 via flow thru 202. D-rings 1905 pivot to allow for alternateball lift sleeve retrieval tool 1901 to fit snugly into ball lift sleeve101.

FIG. 23 illustrates a cut-away side perspective view of the ball liftsleeve 101 and alternate ball lift sleeve retrieval tool 1901. Alternateball lift sleeve retrieval tool 1901 is now securably attached to balllift sleeve 101 via D-rings 1905 disposed in catch groove 201.

FIG. 24 illustrates a partial side perspective view of the ball liftsleeve 101 and alternate ball lift sleeve retrieval tool 1901 in tubing504. The diameter of alternate ball lift sleeve retrieval tool 1901 issuch that it fits snugly in tubing 504.

FIG. 25 illustrates a side perspective view of the ball lift sleeve 101and alternate ball lift sleeve retrieval tool 1901 in tubing 504. Balllift sleeve 101 and alternate ball lift sleeve retrieval tool 1901 aresecurably attached.

In one embodiment of the present invention, any number of of D-rings arepresent.

In one embodiment of the present invention, inner diameter hollowsection 1305 contains a catch groove, like catch groove 201, to allowmultiple ball lift sleeve retrieval tools to be attached to each otheras needed.

In additional embodiments of the present invention, any means to allowthe ball lift sleeve retrieval tool to form a connection with the balllift sleeve for them jointly to be pulled from the well are present.

The present invention reduces wear by minimizing dry runs because ittraps liquid in tubing during after flow cycle by standing valvecharacteristics incorporated by the present invention and reducinghazards and damage at surface. The present invention will operate inflow transition areas. The present invention moves up to transition flowarea to deliver ball to lifting sleeve and start unloading well insmaller runs working its way back to bottom. Properties of surfacetension included in the design of the present invention allows this ifminimal flow is achieved. In horizontal wellbores, the bumper spring ofthe present invention is set in an approximately 40 degree angle(although angle can vary greatly) greatly increasing side friction, thusslowing and stopping sleeve often or pushing it back up to the verticalsection of the tubing until the sleeve weight overcomes the opposingflow to try its dissent again to the ball (the Yo-Yo effect).

This cycle can happen many times before a seal can occur making thereturn trip to surface, causing excessive erosion of lower tubing jointsand sleeve. The present invention moves the liquid load and ball (seal)transferring liquid above sleeve and sealing it for trip to surface,thus shorting run times and minimizing missed runs. The presentinvention can be used to supplement all other lifting plunger typesbecause it can go deeper and operate at greater angles to deliver loadsto where other plungers stop moving because of tight curves and loss ofgravitational force in the horizontal section of tubing. The presentinvention can be retrieved to be checked or replaced easily with aplunger extraction tool, eliminating expensive wire lines. This reducesrequired energy supplements because of optimization of every run, nowasting energy on short runs, dry runs and missed runs. The requiredskill level and time of operator is minimized. If the present inventionstops, it will start again by itself, giving operators a second chanceor third if need to get it running right. This results in overallincreased production.

The best mode for carrying out the invention has been described herein.The previous embodiments are described in sufficient detail to enablethose skilled in the art to make and use the invention. It is to beunderstood that other embodiments would be evident based on the presentdisclosure, and that system, process, or mechanical changes may be madewithout departing from the scope of the present invention.

In the previous description, numerous specific details and examples aregiven to provide a thorough understanding of the invention. However, itwill be apparent that the invention may be practiced without thesespecific details and specific examples. While the invention has beendescribed in conjunction with a specific best mode, it is to beunderstood that many alternatives, modifications, and variations will beapparent to those skilled in the art in light of the foregoingdescription. Accordingly, it is intended to embrace all suchalternatives, modifications, and variations that fall within the scopeof the included claims. All matters previously set forth herein or shownin the accompanying drawings are to be interpreted in an illustrativeand non-limiting sense.

What is claimed is:
 1. A ball lift sleeve and retrieval tool comprising:a sleeve for disposing in tubing of a well, the sleeve defining a firstpassage from a first proximal end to a first distal end; and a retrievaltool for disposing in the tubing of the well, the retrieval tool beingseparately moveable in the tubing between mated and unmated conditionswith respect to the sleeve, the retrieval tool at least partially matingwith the first distal end of the sleeve when in the mated condition andat least partially closing fluid communication through the passage ofthe sleeve when mated therewith.
 2. The apparatus of claim 1, whereinthe sleeve comprises a means for producing a pressure differentialacross the first sleeve.
 3. The apparatus of claim 1, wherein the sleeveand retrieval tool mated together move uphole within the tubing byapplication of a pressure differential.
 4. The apparatus of claim 1,wherein the first distal end of the sleeve comprises a ball seat.
 5. Theapparatus of claim 1, wherein the inner flow thru of the sleevecomprises a catch groove.
 6. The apparatus of claim 1, wherein thedistal end of the retrieval tool comprises a male receiver.
 7. Theapparatus of claim 1, wherein the male receiver of the retrieval toolcomprises a tool catch.
 8. The apparatus of claim 1, wherein the toolcatch of the male receive of the retrieval tool mates with the catchgroove of the sleeve.
 9. The apparatus of claim 1, wherein the malereceiver of the retrieval tool comprises one or more D-rings.
 10. Theapparatus of claim 1, wherein the proximal end of the retrieval toolcomprises a hollow opening extending partly through retrieval tool.